_____________________________________________________________________

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

____________

FORM 8-K

CURRENT REPORT

PURSUANT TO SECTION 13 OR 15 (d)
OF THE SECURITIES EXCHANGE ACT OF 1934

DATE OF EARLIEST EVENT REPORTED: October 31, 2007

ATWOOD OCEANICS, INC.

(Exact name of registrant as specified in its charter)

COMMISSION FILE NUMBER 1-13167

TEXAS
(State or other jurisdiction of incorporation or organization)

Internal Revenue Service – Employer Identification No. 74-1611874

15835 Park Ten Place Drive, Houston, Texas, 77084
(281) 749-7800

____________

Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions (see General Instruction A.2. below):

[ ] Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)

[ ] Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)

[ ] Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))

[ ] Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))

ITEM 7.01 REGULATION FD DISCLOSURE

    Since August 23, 2007, the ATWOOD HUNTER has worked for Burullus Gas Co. (“Burullus”) off the coast of Egypt under a contract that initially we expected to take 140 days to complete at dayrates of $320,000 for the first 90 days, $355,000 for the next 35 days and $410,000 thereafter (which was expected to be 15 days). It currently appears that the rig will complete the Burullus work around the middle of November 2007 and will, thus, not reach the $355,000 or $410,000 dayrate level. Immediately upon completion of its work in Egypt, the rig will return to work under the suspended contract for Woodside Energy Ltd. (“Woodside”) with the rig expected to be moved to Mauritania at a dayrate of $240,000. The Woodside reinstated contract is now expected to be completed in July 2008; however, Woodside has two (2) six month options at dayrates to be mutually agreed, with a new agreement to use the rig beyond its current commitment having to be executed by 15 December 2007. When the Woodside contract is reinstated around the middle of November 2007, ATWOOD HUNTER revenues for the first quarter of fiscal year 2008 will be negatively impacted by approximate $5.5 million ($0.17 reduction in earnings per share) compared to revenues for the quarter that could have been earned if the rig worked the entire period under the Burullus contract.

     In October 2007, the SEAHAWK incurred 15 zero rate days due to equipment downtime which has negatively impacted revenues for the quarter by approximately $1 million ($0.03 reduction in earnings per share). These equipment issues have now been resolved and the rig is currently working at its operating dayrate of approximately $76,000 plus approximately $19,000 of amortized per day revenue.

     The ATWOOD EAGLE continues to work offshore Australia under its contract with BHP Billiton (“BHPB”) which now is expected to take until mid-April 2008 to complete. Upon the rig completing the drilling of its current well (estimated around mid-November 2007), it is expected to incur around 15 zero rate days for required regulatory inspections and planned maintenance. Immediately upon completion of the required inspection and maintenance, the rig will return to work for BHPB to drill three remaining wells at a dayrate of approximately $170,000. Upon completing the BHPB work, the rig will drill one well for ENI Spa AGIP Exploration & Production Division (estimated to take from mid-April 2008 to the end of May 2008 to complete) at a dayrate of $360,000 and then commence a two-year contract for Woodside at a dayrate of $405,000.

     The ATWOOD SOUTHERN CROSS continues to work in the Black Sea under contract commitments with Turkiye Petrolleri A.O. (“TPAO”) and Melrose Resources (“Melrose”). The rig is currently working for TPAO at a dayrate of $290,000. Immediately upon completion of this drilling program (estimated mid-November 2007), the rig will drill three wells for Melrose offshore Bulgaria with a dayrate of $145,000 for the first two wells (estimated to take twenty-five (25) days to thirty-five (35) days complete) and a dayrate of $380,000 for the last well (estimated to take ten (10) days to fifteen (15) days complete). Following the completion of the Melrose work, the rig will drill one remaining well for TPAO at a dayrate of $320,000 (estimated to take thirty (30) to forty-five (45) days to complete). The last TPAO well could be located outside the Black Sea. Following the completion of all commitments in the Black Sea (estimated December 2007 / January 2008), the rig will be mobilized out of the Black Sea to the Mediterranean Sea (estimated to take fifteen (15) to twenty (20) days) at a dayrate of $100,000.

     The RICHMOND was moved to a shipyard in the United States in October 2007 to undergo an approximate $14 million life enhancing upgrade, which is expected (after incurring some weather related delays) to take around seventy (70) days to complete. Following the shipyard period the rig has one well left to drill for Helis Oil & Gas at a dayrate of $80,000 with additional work being pursued.

We currently expect total drilling costs for the first quarter of fiscal year to be $50 million to $52 million, with a projected increase in total drilling costs for fiscal year 2008 compared to fiscal year 2007 of 10% to 12%.

Additional information with respect to the Company’s Fleet Status Report at October 31, 2007 is attached hereto as Exhibit 99.1. Such information is being furnished under Regulation FD and should not be deemed to be filed under Section 19 of the Exchange Act.

Statements contained in this report with respect to the future are forward-looking statements. These statements reflect management's reasonable judgment with respect to future events. Forward-looking statements involve risks and uncertainties. Actual results could differ materially from those anticipated as a result of various factors including; the Company's dependence on the oil and gas industry; the risks involved the construction of a rig; competition; operating risks; risks involved in foreign operations; risks associated with possible disruption in operations due to terrorism; risks associated with a possible disruption in operations due to a war with Iraq; and governmental regulations and environmental matters. A list of additional risk factors can be found in the Company's annual report on Form 10-K for the year ended September 30, 2006, filed with the Securities and Exchange Commission.

ITEM 9.01 EXHIBITS

EXHIBIT 99.1 Fleet Status Report at October 31, 2007

EXHIBIT INDEX

EXHIBIT NO. DESCRIPTION

99.1

Fleet Status Report at October 31, 2007

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.

		ATWOOD OCEANICS, INC
		(Registrant)



		/s/ James M. Holland James M. Holland Senior Vice President

		DATE: October 31, 2007

EXHIBIT 99.1

ATWOOD OCEANICS, INC. AND SUBSIDIARIES FLEET STATUS REPORT
AS OF OCTOBER 31, 2007

As used herein, “we”, “us”, and “our” refers to Atwood Oceanics, Inc. and its subsidiaries, except where the context indicates otherwise. Statements contained in this Fleet Status Report, including information regarding our estimated rig availability, contract duration, future dayrates, future daily operating costs, future effective tax rates, customer or contract status are forward-looking statements. These statements reflect management's reasonable judgment with respect to future events. Forward-looking statements involve risks and uncertainties. Actual results could differ materially from those anticipated as a result of various factors including: our dependence on the oil and gas industry; the risks involved in upgrade, repair and construction of our rigs; competition; operating risks; risks involved in foreign operations; risks associated with possible disruptions in operations due to terrorism; risks associated with a possible disruption in operations due to the war with Iraq and governmental regulations and environmental matters. A list of additional risk factors can be found in our annual report on Form 10-K for the year ended September 30, 2006, filed with the Securities and Exchange Commission. All information in this Fleet Status Report is as of the date indicated above. We undertake no duty to update the content of this Fleet Status Report or any forward-looking statement contained herein to conform the statement to actual results or to reflect changes in our expectations.

CHANGES WILL BE HIGHLIGHTED IN YELLOW

RIG NAME		RATED WATER DEPTH	LOCATION	CUSTOMER	ESTIMATED CONTRACT END DATE		ESTIMATED CONTRACT DAYRATE	UNAUDITED AVERAGE PER DAY OPERATING COSTS (NOT INCLUDING TAX) FOR THE THREE MONTHS ENDED SEPTEMBER 30, 2007 /MONTH ENDED SEPTEMBER 30, 2007 ONLY	ADDITIONAL COMMENTS
SEMISUBMERSIBLES:
ATWOOD EAGLE		5000’	Australia	BHP BILLITON PETROLEUM PTY (“BHPB”)	FIRM WORK – (4 wells) April 2008		1 wells at approximately $160,000 3 well s at approximately $170,000	$ 96,000/$9 3 ,000	Wells are subject to a change in sequence and a portion of the dayrate is subject to some change due to currency exchange rate variance.
			Australia	ENI Spa AGIP EXPLORATION & PRODUCTION DIVISION (“ENI”)	FIRM WORK – (1 well) May 2008		$360,000	N/A	We expect the well to take 40 to 45 days to complete.
			Australia	WOODSIDE ENERGY LTD (“WOODSIDE”)	FIRM WORK – (2 years) May 2010		$405,000	N/A	A portion of the dayrate is subject to some change due to currency exchange rate variance.
			Australia	N/A	N/A		N/A	N/A	The rig is expected to incur around fifteen (15) zero rate days during the first quarter of fiscal year 2008 for required regulatory inspections and planned maintenance.
ATWOOD HUNTER		5,000’	Egypt	BURULLUS GAS CO. (“BURULLUS”)	FIRM WORK – November 2007		$320,000	$ 67,000/$ 72 ,000
			Mauritania	WOODSIDE (Reinstatement of suspended contract)	FIRM WORK July 2008		$240,000
			TBD	WOODSIDE	OPTIONS – Two (2) six-month options. August 2009 , if exercised at negotiated market rate. (Agreement has to be executed by December 2007)		TBD	N/A
			TBD	N/A	N/A		N/A	N/A	The rig could also incur fifteen (15) to twenty (20) zero rate days depending upon the rig’ s drilling schedule in the fourth quarter of fiscal year 2008 for certain equipment upgrades. The rig could incur ten (10) zero rate days in the fourth quarter of fiscal year 2009 for regulatory inspections.
ATWOOD FALCON		5,000’	Malaysia	SARAWAK SHELL BERHAD (“SHELL”) Currently working for Petronas Carigali Sdn. Bhd. under an assignment from Shell. Immediately upon completion of the Petronas work (estimated December 2007), the rig will return to work for Shell.	FIRM WORK – July 2009		$160,000/ $200,000 (dayrate depends on water depth of each well) plus approximately $24,000 of amortized per day revenue	$6 0,000/$ 56 ,000	Most of the work during this period is expected to be at the $160,000 dayrate level. (The rig could incur 5 to 10 zero rate days during the fourth quarter of fiscal year 2008 or first quarter of fiscal year 2009 due to required regulatory inspections.)
			Malaysia	SHELL	OPTION – (1 year)		TBD	N/A
ATWOOD SOUTHERN CROSS	2,000’		Turkey	TURKIYE PETROLLERI A.O. (“TPAO”)	FIRM WORK – November 2007		$290,000	$ 63,000/$74, 000
			Bulgaria	MELROSE RESOURCES (“MELROSE”)	FIRM WORK – December 2007		$145,000	N/A
			Bulgaria	MELROSE	FIRM WORK – December 2007		$380,000	N/A
			Mobilized out of Black Sea (estimated to take 15 to 20 days)	MELROSE	FIRM WORK – December 2007/January 2008		$100,000
			TBD	TPAO	FIRM WORK – January/ February 2008		$320,000	N/A
			TBD	N/A	N/A		N/A	N/A	The rig could incur four to ten zero rate days during the second quarter of fiscal year 2008 for some maintenance work.
CANTILEVER JACK-UPS:
ATWOOD BEACON	400’		India	GUJARAT STATE PETROLEUM CORPORATION LTD (“GSPC”)	FIRM WORK – January 2008		$113,000	$4 5,000/$ 50 ,000
			India	GSPC	FIRM WORK – (12 months) January 2009		$133,500	N/A		The rig could incur three (3) zero rate days during the second quarter of fiscal year 2008 for required inspections.
			India	GSPC	OPTIONS – (1 year)		TBD	N/A

VICKSBURG	300’		Thailand	CHEVRON OVERSEAS PETROLEUM (“CHEVRON”)	FIRM WORK – (2 years) June 2009		$154,000	$42,000/$4 3 ,000
			Thailand	N/A	N/A		N/A	N/A		The rig incurred two (2) zero rate days in July 2007 for required regulatory inspections and one (1) zero rate day in August relating to equipment issues.
SEMISUBMERSIBLE TENDER ASSIST UNIT:
SEAHAWK	1,800’		Equatorial Guinea	AMERADA HESS EQUATORIAL GUINEA, INC. (“HESS”)		FIRM WORK – September 2008	$7 6 , 0 00 (plus approximately $ 19 ,000 of amortized per day revenue.)	$ 78,000/$ 8 5,000		Contract provides for dayrate increases based upon certain cost escalations as well as an approximately $15,000 per day reduction during periods when the rig is being relocated to a new drilling site. Thus far, in the first quarter of fiscal year 200 8, the rig has incurred fifteen (15) zero rate days due to equipment related issues.
			Equatorial Guinea	HESS		OPTIONS – (2 years) September 2010 (if all four six-month options are exercised)	$76,000	N/A		Dayrate subject to increase due to contract cost escalations.
SUBMERSIBLE :
RICHMOND	70’		US Gulf of Mexico	HELIS OIL & GAS		FIRM WORK – December 2007	$80,000	$36,000/$41,000		The rig is currently in a shipyard undergoing an approximate $14 million of life enhancing upgrades, which currently is expected to take around seventy (70) days to complete . The depreciable life of the rig will be extended seven years from January 1, 2008. Work for the rig following the upgrade is currently being pursued.

NOTE – EXPECTED TAX RATE

1) The effective tax rate for fiscal year 2007 is now expected to be around 14%. Virtually all of the Company’s expected tax provision for fiscal year 2007 relates to taxes in foreign jurisdictions. Working in foreign jurisdictions with nontaxable or deemed profit tax systems contribute to the effective tax rate being significantly less than the United States statutory rate.

Other Drilling Costs in Addition to the Above Rig Costs –

PER DAY FOR THE THREE MONTHS SEPTEMBER 2007 $ 17, 000